CN106906002A - The hydrotreating roused using stripper and low pressure separator in distillation stage or hydrogenating conversion process - Google Patents

The hydrotreating roused using stripper and low pressure separator in distillation stage or hydrogenating conversion process Download PDF

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Publication number
CN106906002A
CN106906002A CN201611273066.3A CN201611273066A CN106906002A CN 106906002 A CN106906002 A CN 106906002A CN 201611273066 A CN201611273066 A CN 201611273066A CN 106906002 A CN106906002 A CN 106906002A
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available
pressure
stripper
gas
hydrotreating
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CN201611273066.3A
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CN106906002B (en
Inventor
O·拉热内斯
P-Y·阿尔斯佩克托
P·帕克
N·皮帕
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Axens SA
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Axens SA
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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G67/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only
    • C10G67/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
    • C10G49/22—Separation of effluents
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G5/00—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1022—Fischer-Tropsch products
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/107—Atmospheric residues having a boiling point of at least about 538 °C
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1074—Vacuum distillates
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1077—Vacuum residues
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/207—Acid gases, e.g. H2S, COS, SO2, HCN

Abstract

Facility and method the present invention relates to be used for hydrotreating or hydro-conversion, wherein distillation stage include the stripper operated to the overhead fraction roused available from low pressure separator.

Description

The hydrotreating or hydrogenation roused using stripper and low pressure separator in distillation stage are turned Change method
Technical field
The present invention relates to hydrotreating or the field of hydrogenating conversion process.For hydrotreating or hydro-conversion gas oil, The conventional method of decompression distillate, normal pressure or decompression residuum or the effluent from Fischer-Tropsch unit is generally included for being fractionated The segmentation of the effluent of autoreaction section, it mainly has two purposes, that is, removes H2S and light compounds, and from the list The main fractionation of the product of unit.No matter on absolute value or relative to whole process, realize that the two purposes require the expenditure of energy And represent substantial amounts of investment and running cost high.
Background technology
The method that patent US 3733260 describes the hydrodesulfurization for gas oil, it includes hydrodesulfurization reaction section, The effluent from this section is separated into gas fraction and first liquid cut at high temperature and pressure, the gas phase portion is cold Congeal into and basically comprise the gas fraction and second liquid cut of hydrogen, using the hydrogen of pretreatment from the first and second liquid distillates Stripping H2S and light hydrocarbon, are separated into naphtha and gas oil, and the naphtha is recycled into condensation step by steam stripped hydrocarbon Suddenly.
This configuration needs to produce backflow to be stripped, and with the consumption in the headspace condenser of stripper The shortcoming of some energy included in the effluent from conversion zone.Further, since the optimal temperature needed for being fed to stripper Degree is less than the minimum temperature needed for downstream separation, it means that the charging for the separation must be heated.
Patent US 3371029 describes the method for separating the hydrogeneous effluent from hydrocarbon conversion reactor, wherein Main hydrocarbon is separated into naphtha, gas oil and heavier compound upstream in the absence of stripping H2S and hydrocarbon.
Latter configuration has a disadvantage in that, in removing H2After S, inevitably available from the pressure close to atmospheric pressure The sour gas of the main separation operated under power must be compressed before the fuel gas system of oil plant is returned to.
The present invention separates compressor by minimizing or even saving top, while making the energy efficiency of process maximize Overcome these shortcomings.
Brief description of the drawings
For the identical device of facility, Fig. 1 and Fig. 2 have be identically numbered.
Fig. 1 describes the arrangement of the method according to the invention, wherein being roused from the middle cold separator of pressure to stripper C-1 supplies The bottom fraction of B-4 and succeedingly separate available from conversion zone in high pressure drum B-1 and then middle drum pressure B-3 and then low-pressure drum B-5 The most light cut obtained after the effluent of R-1.
Bottom fraction to main fractionating tower C-2 supplies from drum B-5 and from stripper C-1.
Fig. 2 describes the arrangement of the method according to prior art, wherein both not roused B-5 or not had stripper C-1.To obtain The effluent of autoreaction section R-1 be succeedingly sent to high pressure drum B-1 followed by middle drum pressure B-3 then directly with available from drum B-4 Bottom fraction is sent to main fractionating tower C-2 together.
The content of the invention
The present invention describe for hydrotreating or hydro-conversion gas oil, decompression distillate, normal pressure or decompression residuum or The facility of the effluent from Fischer-Tropsch unit, it at least includes：
Conversion zone R-1,
High pressure heat separator rouses B-1, is supplied available from the effluent of conversion zone R-1 to it, and its bottoms is supplied Separator drum B-5 should be arrived,
Cold high pressure separator rouse B-2, to its supply leave high pressure heat separator rouse B-1 overhead stream, and by its Bottoms are fed to stripper C-1,
Compressional zone K, it is used for available from the gaseous effluent for being referred to as recycle hydrogen of B-2,
Low pressure heat separator rouses B-5, is supplied available from the liquid stream of B-1 to it, and its top gas effluent structure Into a part for the charging of stripper C-1, and its liquid efflunent constitutes the Part I of the charging of fractionating column C-2,
Knockout tower C-1 (also referred to as stripper), the liquid stream available from B-2 and the gas thing available from B-5 are supplied to it Stream, its bottom product constitutes another part of the charging of fractionating column C-2,
Main fractionating tower C-2, the bottom product from stripper C-1 and the liquid stream available from B-5 bottoms are supplied to it, And it isolates following cut：Naphtha (lightweight and heavy), diesel oil, kerosene and residual oil,
A part for hydrogen needed for stove F-1, its charging for being used for heating response section R-1 and/or the conversion zone.
In the variant of facility of the invention, the facility is further included：
Middle pressure heat separator drum B-3, supplies available from the liquid stream of B-1, and its liquid efflunent is supplied to it To drum B-5,
The middle cold separator drum B-4 of pressure, the liquid stream available from B-2 and the gas stream available from B-3 are supplied to it, and Its liquid efflunent constitutes a part for the charging of stripper C-1.
The invention further relates to be carried out at hydrogenation to gas oil, decompression distillate, normal pressure or decompression residuum using above-mentioned facility The method of reason or hydro-conversion.
In the method according to the invention, knockout tower C-1 is generally operated under the following conditions：Gross pressure 0.6 to In the range of 2.0MPa, preferably in the range of 0.7 to 1.8MPa.
In the method according to the invention, fractionating column C-2 is generally operated under the conditions of pressures below：Gross pressure is in 0.1MPa To 0.4MPa, preferably in the range of 0.1MPa to 0.3MPa.
One variant of the method according to the invention, by containing remaining acid gas available from being evaporated at the top of fractionating column C-2 At least a portion divided delivers to the scrubbing tower C-5 for operating under very light pressure, to remove at least a portion H2S, then will The part of overhead fraction is used by the supplement as the fuel in the stove F-1 for conversion zone.
The another variant of the method according to the invention, by containing remaining acid gas available from being evaporated at the top of fractionating column C-2 At least a portion divided delivers to the acid gas compression machine of fluid catalytic cracking unit (FCC).
Finally, the further variant of the method according to the invention, the temperature of high pressure heat separator drum B-1 is so that winner is fractionated The charging of tower C-2 does not need the mode of stove to select.
Detailed description of the invention
The remainder of this specification provides the operating condition on the method and the catalyst used in conversion zone Side information.
Generally, in the method using facility of the invention, conversion zone R-1 can include what serial or parallel connection was set Multiple reactors.
Each reactor of conversion zone includes at least one catalyst bed.Catalyst can make in fixed bed or expanded bed With, or in fact use in ebullated bed.Catalyst, can be at least one in the case of use in fixed bed wherein Multiple catalyst beds are provided in reactor.
Any catalyst well known by persons skilled in the art can be used in the method according to the invention, such as comprising being selected from At least one element in the element of the group VIII (race of the 8th, 9 and 10 of new periodic classification) of periodic classification, and optionally Selected from the catalyst of at least one element in the element of the vib (the 6th race of new periodic classification) of periodic classification.
The operating condition of hydrotreating or hydroconversion reactions section R-1 is generally as follows：
Temperature is usual in the range of about 200 DEG C to about 460 DEG C,
Gross pressure is usual in the range of about 1MPa to about 20MPa, generally in the range of 2 to 20MPa, preferably 2.5 It is to 18MPa and highly preferred in the range of 3 to 18MPa,
The liquid feedstock of each catalytic step it is total when air speed generally in the range of about 0.1 to about 12, preferably about 0.4 To about 10h-1In the range of (when air speed be defined as charging volume flow divided by catalyst volume),
The purity of the recycle hydrogen for using in the method according to the invention is generally in the model of 50 volumes of volume % to 100 % In enclosing,
Relative to liquid feedstock recycle hydrogen amount generally about 50 to about 2500Nm3/m3In the range of.
In order to implement method according to the invention it is possible to there is hydrogenation using at least one being included on amorphous carrier The metal of dehydrogenation functionality or the conventional hydro reforming catalyst of metallic compound.The catalyst can be comprising from group VIII Metal such as nickel and/or cobalt, and be generally combined with the catalyst of at least one metal from vib such as molybdenum and/or tungsten.
As example, it is possible to use the nickel of 0.5 weight of weight % to 10 % being included on gel mineral carrier is (with oxygen Change nickel O represent) and 1 weight of weight % to 30 % molybdenum, preferably the molybdenum of 5 weight of weight % to 20 % is (with molybdenum oxide MoO3Table Show) catalyst.
The total amount of the metal oxide from group vi and viii is generally 5 weight of weight % to 40 %'s in the catalyst In the range of, preferably in the range of 7 weight of weight % to 30 %.Metal (one or more) from group vi with from the Weight ratio (being represented based on metal oxide) of the metal (one or more) of VIII is typically about 20 to about 1, and generally For about 10 to about 2.
Used as example, carrier is selected from aluminum oxide, silica, silica-alumina, magnesia, clay and these ore deposits At least two mixture in thing.
The carrier can also include other compounds, be selected from the oxidation of boron oxide, zirconium oxide, titanium oxide and phosphoric anhydride Thing.
Generally, using alumina support, preferably η or gamma-alumina.
Catalyst can also contain promoter elements, such as phosphorus and/or boron.The element can be introduced into matrix In, or preferably, it can be had been deposited on carrier.Silicon can also be deposited on carrier individually or together with phosphorus and/or boron On.
Preferably, catalyst includes the silicon being deposited on carrier such as aluminum oxide, optionally with the phosphorus being deposited on carrier And/or boron, and also comprising at least one metal (Ni, Co) and at least one gold from vib from group VIII Category (Mo, W).The concentration of the element is generally less than about 20 weight % (based on oxide meter), generally less than about 10%.
Diboron trioxide (B2O3) concentration be typically about 0 to about 10 weight %.
Another catalyst is comprising at least one metal from group VIII and at least one gold from vib The silica-alumina of category.
The another type of catalyst that can be used for the method according to the invention is to contain at least one matrix, at least one The catalyst of Y zeolites and at least one hydrogenation dehydrogenation metal.Above-mentioned matrix, metal and additional elements can also form the catalyst Composition a part.
Described in patent application WO 00/71641, EP 0911077 and US 4738940 and US 4738941 The favourable Y zeolites used under the background of the method according to the invention.
Known some compounds such as basic nitrogen with alkaline nature significantly reduces acid catalyst such as silica-alumina Or the cracking activity of zeolite.The acid properties of catalyst (silica-alumina or even zeolite) are more obvious, by dilution The alkali compounds concentration of reduction is bigger, and this can have favorable influence to mild hydrogenation cracking reaction.
Knockout tower (stripper) C-1 be intended to remove available from cracking gas (commonly referred to sour gas), particularly available from The H of the reaction of conversion zone2S.The tower C-1 can use any stripping gas, such as hydrogen-containing gas or steam.Preferably, make Stripping of the invention is carried out with steam.
In a variant of the invention, knockout tower (stripper) C-1 can boil again.
The pressure of knockout tower C-1 is usually enough to height, and scene is re-introduced into the sour gas that can will be obtained from the separation (site) in fuel gas system, the H contained by the sour gas2S has been cleared by.Gross pressure is generally in about 0.4MPa to about In the range of 2.0MPa, generally in the range of 0.6 to 2.0Ma, preferably in the range of 0.7 to 1.8MPa.
It is preferred that supplying any stripping gas, preferably steam to fractionating column C-2.The gross pressure of fractionating column C-2 generally exists In the range of 0.1MPa to 0.4MPa, preferably in the range of 0.1MPa to 0.3MPa.
Overhead fraction from fractionating column C-2 contains remaining acid gas, and it is being sent to usually using amine scrubbing tower Compressed in compressor K-2 before Sour gas disposal section.After scrubbing, the sour gas cut is then sent to fuel Gas system.
According to the variant, at least a portion of the overhead fraction available from fractionating column C-2 containing remaining acid gas is sent To the scrubbing tower C-5 for operating under very light pressure, to remove at least a portion H2S, the then part of overhead fraction Used as the fuel (by way of supplement) in the stove F-1 for conversion zone.
Further variant of the invention, it is to constitute the charging for catalytic cracking unit that it is particularly well-suited to purpose Hydrodesulfurizationunit unit, at least a portion of the overhead fraction available from fractionating column C-2 containing remaining acid gas is sent to stream The acid gas compression machine of fluidized catalytic cracking unit (FCC).Therefore, this can be used for saving the acidity for hydrodesulfurizationunit unit Gas compressor.
High pressure heat separator drum B-1 generally in slightly lower pressure, such as low 0.1MPa of the pressure than reactor R-1 extremely Operated under the pressure of 1.0MPa.The temperature of heat separator drum B-1 is usual in the range of 200 DEG C to 450 DEG C, preferably at 250 DEG C It is in the range of 380 DEG C and highly preferred in the range of 260 DEG C to 360 DEG C.
According to preferred variant, high pressure heat separator drum B-1 temperature by make main fractionating tower C-2 do not need stove in the way of Selection.
Therefore charging is to rouse B-2 in the pressure than B-1 available from the cold high pressure separator of the gas stream of heat separator drum B1 Operated under slightly lower pressure, such as pressure of the low 0.1MPa to 1.0Mpa of the pressure than B-1.
The gaseous effluent for the being referred to as recycle hydrogen optionally scrubbing in tower C-3 of B-2 is will be obtained from, then in compressor K-1 Middle compression.
In view of live available cooling device, the temperature of cold high pressure separator drum B-2 is generally probably minimum, so that The purity of recycle hydrogen is maximized.
Variant of the invention, the liquid that will be obtained from cold separator drum B-2 depressurizes in valve or turbine, and sends into In the middle cold separator drum B-4 of pressure.Gross pressure in the latter preferably reclaims the gas in the drum separate in an efficient way Pressure needed for the hydrogen included in cut.The hydrogen retrieval is carried out preferably in psa unit.
Pressure in the bulging B-4 is usual in the range of 1.0MPa to 3.5MPa, preferably 1.5MPa's to 3.5MPa In the range of.
In another variant of the invention, the liquid stream that will be obtained from high pressure heat separator drum B-1 delivers to middle pressure thermal release Device rouses B-3.The pressure of the separator drum B-3 rouses B-3 can be supplied to the cold separator drum B-4 of middle pressure in high pressure heat separator The mode of the gas stream of middle separation is selected.
According to preferred variant, a part of liquid that can will be obtained from B-3 is re-introduced into B-2, to promote wherein lightweight The dissolving of hydrocarbon simultaneously maximizes the purity of the hydrogen of recycling gas.
Preferably, will be obtained from it is middle pressure heat separator drum B-3 liquid stream depressurize and be sent to low pressure heat separator drum B-5. Select that the pressure of the bulging B-5 is sufficiently high, the gaseous effluent such that it is able to will be obtained from B-5 is sent to knockout tower C-1.Separator is roused The gross pressure of B-5 generally in the range of about 0.2MPa to about 2.5MPa, generally in the range of 0.3 to 2.0MPa, preferably exists In the range of 0.4 to 1.8MPa.
The present invention is with the difference of prior art：
Compared with wherein in prior art of the main fractionating tower C-2 upstreams in the absence of Fig. 2 of knockout tower, according to the present invention Method in, come autoreactor R-1 effluent light fraction experience be intended to remove these light compounds, particularly H2S Separation.The separation is carried out by stripper C-1.This separation in fractionating column C-2 upstreams can be used to substantially reduce in the master The sour gas at the top of fractionating column C-2, and reduce power and size, and in some cases even can save for The compressor of waste gas.
The steam stripped effluent from reaction zone R-1 is most light in the tower C-1 positioned at main fractionation (tower C-2) upstream Cut is removed by the overhead stream of stripper C-1, and the only heavy end of the effluent of autoreactor in future is (in drum B- The logistics 38 in 5 exit, and stripper C-1 bottoms) be sent to main fractionating tower C-2 after continuous optional decompression.
The temperature of heat separator drum (one or more) obtains fraction products 50,52 and to cause to be supplied to fractionating column C-2 The mode of the heat needed for 55 is selected.According to the present invention, the temperature of high pressure hot drum B-1 can cause that the charging of main fractionating tower is not required to The mode of stove is wanted to select.
Additionally, the fractionation of the heavy effluent from conversion zone R-1 be under minimum pressure in knockout tower C-2 with collect Into mode carry out.Due to being separated more easily by distillation under low pressure, energy efficiency in this way will be changed Enter, especially because the reduction of the energy loss in the aerial condenser of tower top.
Specific embodiment
Following description is carried out by means of Fig. 1, which depict one of the possible embodiment of the method according to the invention. Reaction zone R-1 is hydrocracking zone；However, this is not construed as limiting the invention, the present invention relates to have in main fractionating tower C-2 The separator of upstream rouses the facility of (B-5) and stripper (C-1) sub-assembly.
Charging is the cut with boiling point in the range of 350 DEG C to 530 DEG C, and it is that the heavy vacuum of 70 weight % is distillated The mixture of the heavy gas oil from coking of thing and 30 weight %, with following characteristics：
Proportion 0.965
Sulfur content Weight % 2.8
Nitrogen content Weight ppm 5000
The charging is supplied via pipeline 1 by pump P-1.Supplement hydrogen (excessive preferably with respect to charging) is via pipeline 2 and pressure Contracting machine K-2 and then pipeline 3 are supplied, and are mixed with charging 1 via pipeline 4 before feed-effluent exchanger (E1) is entered.
The pre- hot feed of effluent from hydrocracking reactor R-1 is used using exchanger E-1.The exchange it Afterwards, charging is fed to stove F-1 via pipeline 5 so that its temperature needed for can reaching hydrocracking reaction, then via pipe Line 6 is delivered to the hydro-conversion section being made up of at least one hydrocracking reactor R-1, the hydrocracking reactor by hot feed Comprising at least one hydrocracking catalyst.
Conversion zone R-1 is made up of the reactor of 2 series connection, and each has 3 catalyst beds.First of first reactor It is made up of Axens HMC 868, HF858 and HR844 catalyst.Other beds are made up of Axens HR844 catalyst.
The bed is operated in about 12.5MPa and at a temperature of 350 DEG C to 370 DEG C.The consumption of hydrogen is in conversion zone Relative to the 2% of fresh feed.
Then the effluent of autoreaction in future section delivers to exchanger E-1 via pipeline 10, then delivers to height via pipeline 11 Pressure heat separator drum B-1.Reclaimed by Gas top fraction seperation in the drum and via pipeline 12.
Liquid distillate is reclaimed via pipeline 20 from the bottom of drum B-1.The gas fraction (12) including unreacted hydrogen, The H formed during reaction2S and the light hydrocarbon of the conversion available from the hydrocarbon in the charging of hydrocracking reaction section R-1.
After cooling in exchanger E-2 and aerial condenser A-1, the cut is fed to cold point of high pressure via pipeline 13 B-2 is roused from device to carry out both gas-liquid separation and decantation aqueous liquid phase.After decompression in valve or Liquid turbine V-1, by liquid State hydrocarbon delivers to the cold separator drum B-4 of middle pressure via pipeline 21.
After depressurizing in the valve or Liquid turbine V-2, the liquid efflunent that will be obtained from rousing B-1 is delivered to via pipeline 20 Pressure heat separator drum B-3.Gas fraction is isolated and is reclaimed in the drum and via pipeline 22.Gas fraction includes unreacted Hydrogen, H2S and generally available from conversion zone R-1 charging hydrocarbon conversion light hydrocarbon.
After cooling in aerial condenser A-2, the cut is fed to the cold separator drum B-4 of middle pressure via pipeline 23. Liquid distillate is reclaimed from bottom, low pressure separator is depressurized in valve or Liquid turbine V-3 and delivered to via pipeline 30 and 31 Drum B-5.
The gas fraction that will be obtained from cold high pressure separator drum B-2 delivers to amine absorber or scrubbing tower C-3 via pipeline 14, with Remove at least a portion H2S.Then by the gas fraction containing hydrogen via pipeline 15 and 16 compressed using compressor K-1 and with Hydrocracking reactor is recycled to after the mixing of charging 1.
Supplied via pipeline 32 and 33, valve or Liquid turbine V-5 and exchanger E-3 available from the liquid hydrocarbon effluent of drum B-4 Stripper C-1 should be arrived.
According to preferred variant, steam is preferably added to the top from drum B-1 and/or B-3 via pipeline 60 and 61 In order to be fractionated in effluent.The water is separated in drum B-2 and B-4, and is discharged via pipeline 57 after isolation.Will be in drum B- The water in 2 separate delivers to bulging B-4 via pipeline 56 and valve V-4.Pipeline 58 can be used to discharge gas stream.
Stripper C-1 is at the tower top for 0.9MPa, reflux drum B-6 are 45 DEG C and bottom temp is to operate at 180 DEG C.
Gas fraction is separated in drum B-5.The gas fraction is fed to stripper C-1 via pipeline 34.To stripper C-1 is supplied via pipeline 35 with every 1 standard m3The stripped vapor of the ratio of tower bottom product 7kg/h steam.From the top of stripper, Via the gas recovery cut of pipeline 36 (commonly referred to sour gas), and via pipeline 37 by means of drum B-6 and exchanger E-6 Reclaim the naphtha of the final boiling point with typically larger than 100 DEG C.The liquid reclaimed from stripper bottom is delivered to via pipeline 39 Main fractionating tower C-2, without being reheated in stove or exchanger.
The liquid distillate that will be obtained from rousing B-5 direct supplies to main fractionating tower C-2 via pipeline 38, without in stripper Or boil the operation of separating acid gas is carried out in knockout tower again.
Main fractionating tower C-2 is low pressure, the reflux drum B-7 of 0.29MPa at tower top for 45 DEG C (by aerial condenser A- After 3 and pump P-2), bottom temp be 330 DEG C at operate.Heat needed for separating preferably is operated by under 340 DEG C and 1.1MPa Heat separator drum B-5 temperature supply.Also to tower C-2 supplies via pipeline 40 with every 1 standard m3Tower bottom product 7kg/h steams The stripped vapor of the ratio of vapour.
The overhead fraction reclaimed via pipeline 41 contains the sour gas of residual, and it is (logical in output to Sour gas disposal It is often amine scrubber or scrubbing tower) before, and pressed in compressor K-2 before delivering to fuel gas system via pipeline 42 Contracting.
Variant of the invention, delivers to what is operated under very light pressure by the sour gas of residual via pipeline 43 Amine absorber or scrubbing tower C-5, it can be removed before the fuel in being used as the stove F-1 of conversion zone via pipeline 44 to lesser extent Remove at least a portion H2S。
Another variant of the invention, it is to constitute the charging for catalytic cracking unit to be particularly suited for purpose Hydrodesulfurizationunit unit, these sour gas for remaining are sent to the acid gas compression of fluid catalytic cracking unit via pipeline 45 Machine.
It is made up of naphtha cut available from the product of pipeline 50 via pump P-3, its whole boiling for being typically below 200 DEG C Point.
By the inter-chamber tower C-4 (optional) by being optionally equipped with reboiler E-7 from main fractionating tower C-2 via pipeline 51 midbarrels for obtaining for example are cooled down after by pump P-5 by means of exchanger E-4, are then reclaimed via pipeline 52. For example, there is the gas oil fraction of 95 volume % vapo(u)rizing temperatures (NF EN iso standards 3405) less than 360 DEG C.
The heavy end that will also be obtained via pipeline 53 and 54 from main fractionating tower is after by pump P-4 by means of friendship Parallel operation E-5 is cooled down.Thus the cut for being obtained via pipeline 55 is that have the pressure reduction gas close to the recovered (distilled) temperature of initial charge Oil.
According to another embodiment, can via pipeline 50 reclaim from naphtha to the cut of lightweight gas oil and via Pipeline 55 reclaims supplement heavy gas oil fraction.In this case, fractionating column C-2 be not included in C-4 intermediate fractionation and In the absence of pipeline 51 and 52.
According to another embodiment of fractionating column C-2, can be taken off the kerosene and diesel oil distillate (figure as side logistics Not shown in 1).
Embodiment
Table 1 compares mild hydrogenation cracking method (Fig. 2) according to prior art i.e. without stripper C-1 and according to this hair It is bright to use the mild hydrogenation cracking method (Fig. 1) of drum B-5 and stripper C-1.
Table 1
In the method according to the invention, the top that must be compressed in compressor K-2 from low pressure main fractionating tower The amount (logistics 41) of sour gas divided by 6 (107kg/h compared with 608kg/h) compared with the method according to prior art.
(according to Fig. 2) in the case of the mild hydrogenation cracking according to prior art, will be from middle pressure heat separator drum B-3 Bottom fraction and the whole of the bottom fraction from the cold bulging B-4 of middle pressure be fed to fractionating column C-2.
In the method according to the invention (Fig. 1), the temperature of low pressure heat separator drum B-5 is 340 DEG C, it means that can be with Save the stove for heating the charging 38 that tower C-2 is taken out and be fed to from the bottom of low-pressure drum B-5.

Claims (7)

1. hydrotreating or hydro-conversion gas oil, decompression distillate, normal pressure or decompression residuum are used for or from Fischer-Tropsch unit The facility of effluent, the facility at least includes：
Conversion zone R-1,
High pressure heat separator rouses B-1, is supplied available from the effluent of conversion zone R-1 to it, and its bottoms is fed to Separator rouses B-5,
Cold high pressure separator rouses B-2, and the overhead stream that high pressure heat separator rouses B-1 is left to its supply, and by its bottom Logistics supply to stripper C-1,
Compressional zone K, it is used for available from the gaseous effluent for being referred to as recycle hydrogen of B-2,
Low pressure heat separator rouses B-5, is supplied available from the liquid stream of B-1 to it, and its top gas effluent constitutes vapour A part for the charging of stripper C-1, and its liquid efflunent constitutes the Part I of the charging of fractionating column C-2,
Knockout tower C-1 (also referred to as stripper), the liquid stream available from B-2 and the gas stream available from B-5 are supplied to it, Its bottom product constitutes another part of the charging of fractionating column C-2,
Main fractionating tower C-2, the bottom product from stripper C-1 and the liquid stream available from B-5 bottoms are supplied to it, and It isolates following cut：Naphtha (lightweight and heavy), diesel oil, kerosene and residual oil,
A part for hydrogen needed for stove F-1, its charging for being used for heating response section R-1 and/or the conversion zone.
2. facility as claimed in claim 1, the facility is further included：
Middle pressure heat separator drum B-3, supplies available from the liquid stream of B-1, and its liquid efflunent is fed into drum to it B-5,
The middle cold separator drum B-4 of pressure, the liquid stream available from B-2 and the gas stream available from B-3, and its liquid are supplied to it Body effluent constitutes a part for the charging of stripper C-1.
3. carry out hydrotreating using the facility as described in claim 1 or claim 2 or hydro-conversion gas oil, decompression are distillated The method of thing, normal pressure or decompression residuum, wherein knockout tower C-1 is operated under the following conditions：Gross pressure is in 0.6 to 2.0MPa scopes It is interior, preferably in the range of 0.7 to 1.8MPa.
4. come hydrotreating or hydro-conversion gas oil, decompression distillate, normal pressure using facility as claimed in claim 3 or subtract The method for pressing residual oil, wherein fractionating column C-2 is operated under the conditions of pressures below：Gross pressure in the range of 0.1MPa to 0.4MPa, It is preferred that in the range of 0.1MPa to 0.3MPa.
5. hydrotreating as described in claim 3 or claim 4 or hydro-conversion gas oil, decompression distillate, normal pressure or The method of decompression residuum, wherein at least a portion of the overhead fraction available from fractionating column C-2 containing remaining acid gas is sent To the scrubbing tower C-5 for operating under very light pressure, to remove at least a portion H2S, then by the portion of overhead fraction Divide and used by the supplement as the fuel in the stove F-1 for conversion zone.
6. hydrotreating as described in any one of claim 3 to 5 or hydro-conversion gas oil, decompression distillate, normal pressure subtract The method for pressing residual oil, wherein at least a portion of the overhead fraction available from fractionating column C-2 containing remaining acid gas is delivered to The acid gas compression machine of fluid catalytic cracking unit (FCC).
7. hydrotreating as described in any one of claim 3 to 6 or hydro-conversion gas oil, decompression distillate, normal pressure subtract Press residual oil method, wherein high pressure heat separator drum B-1 temperature by make main fractionating tower C-2 charging do not need stove in the way of Selection.
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WO2022079051A1 (en) * 2020-10-14 2022-04-21 Shell Internationale Research Maatschappij B.V. Systems and processes for generating a reduced chloride stripped fluid from a hydroprocessing effluent
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US11028330B2 (en) 2021-06-08

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